Compositions and methods using subterranean treatment fluids comprising water-soluble polymers

ABSTRACT

Compositions and methods using subterranean treatment fluids comprising water-soluble polymers are provided. In some embodiments, the methods include: adding an anionic or amphoteric water-soluble polymer to a treatment fluid comprising an aqueous base fluid; adding a dewatering agent to the treatment fluid, wherein the dewatering agent comprises an aqueous phase, a solvent, a co-solvent, and one or more surfactants selected from the group consisting of: ethoxylated alcohol, a polyamine polyether, a resin alkoxylated oligomer, and any combination thereof; and introducing the treatment fluid into a well bore penetrating at least a portion of the subterranean formation.

BACKGROUND

The present disclosure relates to compositions and methods for treatinga subterranean formation.

Treatment fluids may be used in a variety of subterranean treatmentoperations. As used herein, the terms “treat,” “treatment,” “treating,”and grammatical equivalents thereof refer to any subterranean operationthat uses a fluid in conjunction with achieving a desired functionand/or for a desired purpose. Use of these terms does not imply anyparticular action by the treatment fluid. Illustrative treatmentoperations may include, for example, fracturing operations, gravelpacking operations, acidizing operations, scale dissolution and removal,consolidation operations, and the like. For example, a fluid may be usedto drill a well bore in a subterranean formation or to complete a wellbore in a subterranean formation, as well as numerous other purposes.

Friction reducers are typically included in treatment fluids duringpumping into a well bore penetrating a subterranean formation tominimize damage to the formation. Generally, friction reducers comprisea chemical additive that functions to alter the rheology of thetreatment fluid by increasing the viscosity and lowering the friction.Friction reducers may be high molecular weight polymers, such as thosehaving a molecular weight of at least about 2,500,000. Such polymers maybe linear and flexible. Suitable friction reducers include water-solublepolymers.

One example of a treatment fluid that may utilize a friction reducer isa hydraulic fracturing fluid. Hydraulic fracturing is a process commonlyused to increase the flow of desirable fluids, such as oil and gas, froma portion of a subterranean formation. In hydraulic fracturing, afracturing fluid may be introduced into the subterranean formation at orabove a pressure sufficient to create or enhance one or more factures inthe formation. Enhancing a fracture may include enlarging a pre-existingfracture in the formation. Friction reducers may be included in thefracturing fluid to reduce frictional energy losses within the fluid andto increase the viscosity under low shear forces, such as withinfractures, to aid in the placement of proppant particulates in thefractures.

BRIEF DESCRIPTION OF THE DRAWINGS

These drawings illustrate certain aspects of some of the embodiments ofthe present disclosure and should not be used to limit or define theclaims.

FIG. 1 is a diagram illustrating an example of a subterranean formationin which a fracturing operation may be performed in accordance withcertain embodiments of the present disclosure.

FIG. 2 is a graph illustrating viscosity measurements of compositions inaccordance with certain embodiments of the present disclosure.

FIG. 3 is a graph illustrating the percentage of friction reduction forcompositions in accordance with certain embodiments of the presentdisclosure.

While embodiments of this disclosure have been depicted, suchembodiments do not imply a limitation on the disclosure, and no suchlimitation should be inferred. The subject matter disclosed is capableof considerable modification, alteration, and equivalents in form andfunction, as will occur to those skilled in the pertinent art and havingthe benefit of this disclosure. The depicted and described embodimentsof this disclosure are examples only, and not exhaustive of the scope ofthe disclosure.

DESCRIPTION OF CERTAIN EMBODIMENTS

The present disclosure relates to compositions and methods for treatinga subterranean formation. More particularly, the present disclosurerelates to compositions and methods for using in subterranean treatmentfluids comprising water-soluble polymers used to treat subterraneanformations.

The present disclosure provides compositions comprising a frictionreducer and a dewatering agent. The friction reducer may be an anionicor amphoteric water-soluble polymer. The dewatering agent may comprisean aqueous phase, a solvent, a co-solvent, and at least one surfactant.In certain embodiments, the friction reducer and the dewatering agentmay be added to a treatment fluid having an aqueous base fluid. Incertain embodiments, the treatment fluid may further comprise aplurality of proppant particulates.

The present disclosure also provides methods of treating a subterraneanformation using the compositions of the present disclosure. In certainembodiments, the methods of the present disclosure comprise introducinga treatment fluid comprising an aqueous base fluid, a water-solublepolymer, and a dewatering agent into a well bore penetrating asubterranean formation. In certain embodiment, the methods of thepresent disclosure comprise adding a water-soluble polymer and adewatering agent, either together or separately, into a treatment fluidand/or a well bore penetrating a subterranean formation. In someembodiments, the water-soluble polymer and the dewatering agent may beadded to a treatment fluid before or after the treatment fluid isintroduced into the well bore. In certain embodiments, the methods ofthe present disclosure may further comprise introducing the treatmentfluid into one or more fractures within the subterranean formation.

Among the many potential advantages to the methods and compositions ofthe present disclosure, only some of which are alluded to herein, themethods and compositions of the present disclosure may increase theviscosity of treatment fluids while maintaining friction reductionabilities (e.g., turbulence reduction) and, in some embodiments, may doso without increasing water-soluble polymer concentration. The methodsand compositions of the present disclosure may also aid in suspension ofproppant within the treatment fluid and/or placement of proppant infractures within subterranean formation.

The treatment fluids of the present disclosure may include any aqueousbase fluid known in the art. In certain embodiments, the aqueous basefluid may be present in the treatment fluid in an amount from about 0.5weight (“wt.”) % to about 99 wt. % by volume of the treatment fluid. Theterm “base fluid” refers to the major component of the fluid (as opposedto components dissolved and/or suspended therein), and does not indicateany particular condition or property of that fluids such as its mass,amount, pH, etc. Aqueous fluids that may be suitable for use in themethods and systems of the present disclosure may include water from anysource. Such aqueous fluids may include fresh water, salt water (e.g.,water containing one or more salts dissolved therein), brine (e.g.,saturated salt water), seawater, or any combination thereof. In mostembodiments of the present disclosure, the aqueous fluids include one ormore ionic species, such as those formed by salts dissolved in water.For example, seawater and/or produced water may include a variety ofmonovalent and/or divalent cationic species dissolved therein. Incertain embodiments, the one or more ionic species may be selected fromthe group consisting of: H, Li, Na, K, Cs, Be, Mg, Ca, Sr, Ba, Cr, Fe,Mn, Co, Ni, Cu, Ga, In, NH₄, and any combination thereof. In certainembodiments, the density of the aqueous fluid may be adjusted, amongother purposes, to provide additional particulate transport andsuspension in the compositions of the present disclosure. In certainembodiments, the treatment fluids may include a mixture of one or moreaqueous fluids with other fluids and/or gases, including but not limitedto emulsions, foams, and the like.

The treatment fluids of the present disclosure may comprise a frictionreducer. In certain embodiments, the treatment fluid may comprise thefriction reducer in an amount from about 0.05 wt. % to about 1.5 wt. %by volume of the treatment fluid. In other embodiments, the treatmentfluid may comprise the friction reducer in an amount from about 0.1 wt.% to about 1.0 wt. % by volume of the treatment fluid. In otherembodiments, the treatment fluid may comprise the friction reducer in anamount from about 0.2 wt. % to about 0.6 wt. % by volume of thetreatment fluid. In certain embodiments, the friction reducer may be inan emulsion when added to the treatment fluid.

In certain embodiments, the friction reducer may comprise one or morewater-soluble polymers. In certain embodiments, the water-solublepolymers may have a molecular weight from about 100,000 g/mol to about20,000,000 g/mol. In certain embodiments, the water-soluble polymers maybe anionic or amphoteric. In certain embodiments, the water-solublepolymers may comprising one or more of the following monomers: acrylicacid, 2-acrylamido-2-methylpropane sulfonic acid (AMPS),2-(meth)acrylamido-2-methylpropane sulfonic acid,2-amino-2-methyl-1-propanol (AMP), N,N-dimethylacrylamide (DMF), vinylsulfonic acid, N-vinyl acetamide, N-vinyl formamide, itaconic acid,methacrylic acid, acrylic acid ester, methacrylic acid ester,acrylonitrile (including hydrolyzed products of acrylonitrile residues),acrylonitrile-dimethyl amine reaction products, [2-(acryloyloxy)ethyl]trimethylammonium chloride (AETAC), acrylamide (including alkyl-, aryl-,alkenyl-, and di-substituted derivatives thereof), (C₁ to C₃₀) acrylicesters, any salts thereof, and any combination thereof.

In certain embodiments, the water-soluble polymer may comprise alatex-based component. As used herein, the term “latex-based component”refers to one or more monomers having at least one vinyl moiety that areemulsified with one or more surfactants in mineral oil and water andpolymerized. In certain embodiments, the water-soluble polymer may be anemulsion polyacrylate-based material. In some embodiments, thewater-soluble polymer may have the following chemical formula:CH₂CHC(O)NR¹ ₂, CH₂C(CH₃)C(O)NR¹ ₂, CH₂CH(CH₂)_(n)C(O)NR¹ ₂, orCH₂C(CH₃)(CH₂)_(n)C(O)NR¹ ₂. In such embodiments, n may be an integerfrom about 0 to about 6. R¹ may be selected from the group consistingof: —H, —C₂H₄OH, —CH₃, —(CH₂)_(m)CH₃, wherein m is an integer from about2 to about 25. In other embodiments, the water-soluble polymer may havethe following chemical formula: (CH₂CH)C(O)OR², CH₂C(CH₃)C(O)OR²,CH₂CH(CH₂)_(n)C(O)OR², or CH₂C(CH₃)(CH₂)_(n)C(O)OR². In suchembodiments, n may be an integer from about 0 to about 6. R² may beselected from the group consisting of: —H, a (C₁ to C₂₀) hydrocarbonchain, or a counterion. The counterion ion may be selected from thegroup consisting of: Li, Na, K, Cs, Be, Mg, Ca, Sr, Ba, Cr, Fe, Mn, Co,Ni, Cu, Ga, In, and NH₄. In one embodiment, the friction reducercomprises a first water-soluble polymer having the chemical formula:CH₂CHC(O)NR¹ ₂, CH₂C(CH₃)C(O)NR¹ ₂, CH₂CH(CH₂)_(n)C(O)NR¹ ₂, orCH₂C(CH₃)(CH₂)_(n)C(O)NR¹ ₂, as described above, in an amount from about50 wt. % to about 85 wt. % by weight of the friction reducer and asecond water-soluble polymer having the chemical formula:(CH₂CH)C(O)OR², CH₂C(CH₃)C(O)OR², CH2CH(CH₂),C(O)OR², orCH₂C(CH₃)(CH₂)_(n)C(O)OR², as described above, in an amount from about15 wt. % to about 50 wt. % by weight of the friction reducer.

As used herein, the term “hydrocarbon” refers to a molecule orfunctional group that includes at least carbon and hydrogen atoms.Hydrocarbon chains are referred to herein using (C_(a) to C_(b)),wherein a and b are positive integers that designate a range of thenumber of carbon atoms that the hydrocarbon may contain. A hydrocarbonchain may be or contain an alkyl group, an alkenyl group, an alkynylgroup, an aryl group, a cycloalkyl group, an acyl group, or anycombination thereof. Unless otherwise specified herein, a hydrocarbonchain as used herein may be substituted or unsubstituted and branched orunbranched.

The treatment fluids of the present disclosure may comprise a dewateringagent. In certain embodiments, the treatment fluid may comprise thedewatering agent in an amount from about 0.001 wt. % to about 4.0 wt. %by volume of the treatment fluid. In other embodiments, the treatmentfluid may comprise the dewatering agent in an amount from about 0.01 wt.% to about 2.0 wt. % by volume of the treatment fluid. In otherembodiments, the treatment fluid may comprise the dewatering agent in anamount from about 0.05 wt. % to about 1.5 wt. % by volume of thetreatment fluid.

In certain embodiments, the dewatering agent may comprise an aqueousphase. In certain embodiments, the dewatering agent may be an aqueousexternal emulsion. The aqueous phase of the dewatering agent maycomprise any suitable water, such as fresh water, de-ionized water, saltwater, brine, produced water, flowback water, brackish water, or seawater. In certain embodiments, the water may be a salt water or brine.In such embodiments, the salt may be any suitable salt, such as at leastone of NaBr, CaCl₂, CaBr₂, ZnBr₂, KCl, NaCl, a carbonate salt, asulfonate salt, sulfite salts, sulfide salts, a phosphate salt, aphosphonate salt, a magnesium salt, a bromide salt, a formate salt, anacetate salt, and a nitrate salt. In certain embodiments, the water mayhave a concentration of at least one salt from about 0.1 wt. % to about20 wt. % by volume of the water.

In certain embodiments, the aqueous phase may be present in thedewatering agent in an amount from about 0.001% to about 80% by volume,based on the volume of the dewatering agent. In other embodiments, theaqueous phase may be present in the dewatering agent in an amount fromabout 20% to about 80% by volume, based on the volume of the dewateringagent. In other embodiments, the aqueous phase may be present in thedewatering agent in an amount from about 30% to about 70% by volume,based on the volume of the dewatering agent. In other embodiments, theaqueous phase may be present in the dewatering agent in an amount fromabout 40% to about 60% by volume, based on the volume of the dewateringagent.

In certain embodiments, the dewatering agent may comprise a solvent. Asused herein, the term “solvent” refers to a substance that can dissolveone or more solutes (e.g., a chemically distinct liquid, solid, or gas)to form a solution. The solvent of the dewatering agent may comprisemethyl 9-decenoate, methyl 9-dodecenoate, N,N-dimethyl 9-decenamide,diethyl carbonate, triethyl citrate, dimethyl 2-methylglutarate, dodecylacetate, 1-dodecyl-2-pyrrolidinone, 2-dodecyl-pyrrolidinone,N—(C₂H₄)_(n)CH₃-pyrrolidinone (wherein n is from about 1 to about 22),n-octyl-pyrrolidinone, dibutyl ether, isoamyl ether, di-n-amyl ether,dihexyl ether, heptyl ether, dioctyl ether, dodecyl ether, benzyl hexylether, branched or linear di-n-alkyl-ethers having the formulaO[(CH₂)_(x)CH₃]₂ (wherein x is from about 3 to about 35), a dibasicester having the formula CH₃OC(O)(CH₂)_(m)C(O)OCH₃ (wherein m is fromabout 2 to about 4), and any combination thereof. In certainembodiments, the solvent of the dewatering agent may comprise a lineardibasic ester, a branched dibasic ester, and any combination thereof. Incertain embodiments, the solvent of the dewatering agent may be selectedfrom the group of dimethyl 2-methylglutarate, 1-dodecyl-2-pyrrolidinone,N—(C₂H₄)_(n)CH₃-pyrrolidinone (wherein n is from about 6 to about 12),dimethyl succinate, dimethyl glutarate, dimethyl adipate, and anycombination thereof. In other embodiments, the solvent of the dewateringagent may be dimethyl 2-methylglutarate.

In certain embodiments, the solvent may be present in the dewateringagent in an amount from about 0.01% to about 50% by volume, based on thevolume of the dewatering agent. In other embodiments, the solvent may bepresent in the dewatering agent in an amount from about 0.1% to about25% by volume, based on the volume of the dewatering agent. In otherembodiments, the solvent may be present in the dewatering agent in anamount from about 1.0% to about 20% by volume, based on the volume ofthe dewatering agent. In other embodiments, the solvent may be presentin the dewatering agent in an amount from about 2.0% to about 15% byvolume, based on the volume of the dewatering agent. In otherembodiments, the solvent may be present in the dewatering agent in anamount from about 2.5% to about 10% by volume, based on the volume ofthe dewatering agent.

In certain embodiments, the dewatering agent may comprise a co-solvent.As used herein, the term “co-solvent” refers to a substance that candissolve one or more solutes (i.e., a chemically distinct liquid, solid,or gas) to form a solution and enhance the solvency of another solvent.The co-solvent of the dewatering agent may comprise any alcohol that isat least partially miscible with water. In certain embodiments, theco-solvent may be an alcohol that is branched or unbranched and primary,secondary, or amyl. In certain embodiments, the co-solvent may be:methanol, ethanol, n-propanol, isopropanol, n-butanol, 2-butanol,n-pentanol, 1-hexanol, 2-hexanol, neopentyl alcohol, isodecyl alcohol,isotridecyl alcohol, allyl alcohol, crotyl alcohol, 3-buten-2-ol,2-methyl-2-propen-1-ol, propargyl alcohol, cyclic-secondary alcohols, orany combination thereof.

In certain embodiments, the co-solvent may be present in the dewateringagent in an amount from about 0.5% to about 85% by volume, based on thevolume of the dewatering agent. In other embodiments, the co-solvent maybe present in the dewatering agent in an amount from about 1.0% to about60% by volume, based on the volume of the dewatering agent. In otherembodiments, the co-solvent may be present in the dewatering agent in anamount from about 5.0% to about 50% by volume, based on the volume ofthe dewatering agent. In other embodiments, the co-solvent may bepresent in the dewatering agent in an amount from about 15% to about 45%by volume, based on the volume of the dewatering agent. In otherembodiments, the co-solvent may be present in the dewatering agent in anamount from about 20% to about 35% by volume, based on the volume of thedewatering agent.

In certain embodiments, the dewatering agent may comprise one or moresurfactants. In certain embodiments, the surfactants may be selectedfrom the group consisting of: an ethoxylated surfactant, a polyaminepolyether, a resin alkoxylated oligomer, and any combination thereof.The surfactants of the dewatering agent may be present in the dewateringagent in an amount from about 0.1% to about 30% by volume, based on thevolume of the dewatering agent. The surfactants of the dewatering agentmay be present in the dewatering agent in an amount from about 5% toabout 25% by volume, based on the volume of the dewatering agent. Thesurfactants of the dewatering agent may be present in the dewateringagent in an amount from about 10% to about 20% by volume, based on thevolume of the dewatering agent. In one embodiment, the dewatering agentmay comprise an ethoxylated surfactant, a polyamine polyether, and aresin alkoxylated oligomer, each present in the dewatering agent in anamount from about 2.0% to about 10% by volume, based on the volume ofthe dewatering agent. In another embodiment, the dewatering agent maycomprise an ethoxylated surfactant, a polyamine polyether, and a resinalkoxylated oligomer, each present in the dewatering agent in an amountfrom about 3.0% to about 7.0% by volume, based on the volume of thedewatering agent. In another embodiment, the dewatering agent maycomprise an ethoxylated surfactant, a polyamine polyether, and a resinalkoxylated oligomer, each present in the dewatering agent in about 5.0%by volume, based on the volume of the dewatering agent.

The ethoxylated surfactant of the dewatering agent may function, interalia, as a surface tension modifier. In certain embodiments, theethoxylated surfactant of the dewatering agent may be selected from thegroup of ethoxylated alcohols, ethoxylated amines, ethoxylated esters,ethoxylated amides, secondary alcohol ethoxylates having from 6 to 25carbon atoms and 1 to 18 ethylene oxide groups, and any combinationthereof. In certain embodiments, the ethoxylated surfactant may beselected from linear, primary tridecyl alcohol ethoxylates having from12 to 18 carbon atoms and 18 ethylene oxide units, secondary alcoholethoxylates having 15 carbon atoms and 15 ethylene oxide units, and anycombination thereof. In other embodiments, the ethoxylated surfactantmay be one or more linear, primary alcohol ethoxylates having from 12 to14 carbon atoms and 7 ethylene oxide units. In certain embodiments, theethoxylated surfactant may be an ethoxylated alcohol may have thefollowing chemical formula: RO(CH₂CH₂O)_(n)H, where R is a hydrocarbonchain and n is an integer. In certain embodiments, R may be a (C₈ toC₂₅) hydrocarbon chain. In other embodiments, R may be a (C₁₀ to C₂₀)hydrocarbon chain. In other embodiments, R may be a (C₁₂ to C₁₄)hydrocarbon chain. In certain embodiments, n is an integer from about 3to about 20. In certain embodiments, n is an integer from about 5 toabout 18. In other embodiments, n is an integer from about 7 to about14.

In certain embodiments, the polyamine polyether may be selected from thegroup of polyols, amine oxyalkylates, alkoxylated polyamines,amine-initiated polyol block copolymers, ethylenediamine ethoxylatedand/or propoxylated, polyethyleneimine polymers, and any combinationthereof. In certain embodiments, the polyamine polyether in thedewatering agent may be a polyol. Examples of polyols suitable for useas the polyamine polyether of the dewatering agent are sold by Solvay inassociation with the names and trade designations Clearbreak® 195,Clearbreak® 217, and Clearbreak® 218. Additional examples of polyolssuitable for use as the polyamine polyether of the dewatering agent aresold by Croda in association with the names and trade designationsKemelix® D317, Kemelix D501, Kemelix® D503, Kemelix®D506, Kemelix® D511,Synperonic® PE/L121, and Synperonic® PE/L64. Additional examples ofpolyols suitable for use as the polyamine polyether of the dewateringagent are sold by Huntsman in association with the names and tradedesignations Surfonic® OFD 101, Surfonic® OFD 328, Surfonic® OFD 335,Surfonic® POA-17R2, Jeffox® WL 660, and Jeffox WL 5000. Additionalexamples of polyols suitable for use as the polyamine polyether of thedewatering agent are sold by Dow in association with the names and tradedesignations Demtrol® 1010, Demtrol® 1020, Demtrol® 1030, Demtrol® 1040,Demtrol® 1113, Demtrol® 1114, Demtrol® 1115, and Demtrol® 1130.

In certain embodiments, the polyamine polyether in the dewatering agentmay be an amine oxyalkylate. An example of an amine oxyalkylate that issuitable for use as the polyamine polyether of the dewatering agent issold by Solvay in association with the name and trade designationClearbreak® 291. Additional examples of amine oxyalkylates suitable foruse as the polyamine polyether of the dewatering agent are sold byAkzoNobel in association with the names and trade designations Witbreak™DPG-482, Witbreak™ DRI-9026, Witbreak™ GT-705, Witbreak™ GT-750, andWitbreak™ GT-756.

In certain embodiments, the polyamine polyether in the dewatering agentmay be an alkoxylated polyamine. Examples of alkoxylated polyamines thatare suitable for use as the polyamine polyether of the dewatering agentare sold by Huntsman in association with the names and tradedesignations Surfonic® OFD 150, Surfonic® OFD 300, Surfonic® OFD 301,Surfonic® OFD 302, and Surfonic® OFD 360. Additional examples ofalkoxylated polyamines that are suitable for use as the polyaminepolyether of the dewatering agent are sold by BASF in association withthe names and trade designations Basorol® DB-9904, Basorol® P DB-5951,and Basorol® 904. In certain embodiments, the polyamine polyethersurfactant may have the following structure:

In such embodiments, R₁ and R₂ each may be independent selected from thegroup consisting of: an alkyl, an alkenyl, a vinyl, an allyl, analkynyl, an aryl, a phenyl, a benzyl, and a proparyl. In suchembodiments, X may be an oxyalkoxo group having the following structure:

in which W may be a (C₁ to C₅) alkylene, 2-methyl propylene,2,2-dimethyl propylene, or have one of the following structures:

wherein y is an integer representing from about 0 to about 6 methyleneunits.

In certain embodiments, the polyamine polyether surfactant may have thefollowing structure:

wherein M₁, M₂, M₃, and M₄ each have the following structure:

In such embodiments, R may be selected from the group consisting of:methyl, ethyl, and propyl. R₁ and R₂ each may be independent selectedfrom the group consisting of: an alkyl, an alkenyl, a vinyl, an allyl,an alkynyl, an aryl, a phenyl, a benzyl, and a proparyl. The variable“z” may be an integer from about 1 to about 25. In such embodiments, R,R₁, and R₂ may be the same or different across M₁, M₂, M₃, and M₄. Forexample, in certain embodiments, M₁ may be identical to one or more ofM₂, M₃, M₄, and, in certain embodiments, M₁ may be different than atleast one of M₂, M₃, and M₄.

In certain embodiments, the polyamine polyether in the dewatering agentmay be an amine-initiated polyol block copolymer. Examples ofamine-initiated polyol block copolymers that are suitable for use as thepolyamine polyether of the dewatering agent are sold by Dow inassociation with the names and trade designations Demtrol® 4026,Demtrol® 4017, Demtrol® 4110, Demtrol® 4115, and Demtrol® 4120.

In certain embodiments, the polyamine polyether in the dewatering agentmay be an ethylenediamine ethoxylated and/or propoxylated,polyethyleneimine polymer. Examples of ethylenediamine ethoxylatedand/or propoxylated, polyethyleneimine polymers that are suitable foruse as the polyamine polyether of the dewatering agent are sold by Crodain association with the names and trade designations Kemelix® 3216x,Kemelix® 3422X, Kemelix® 3551X, Kemelix® 3515X, Kemelix® D510, andKemelix® D513. Additional examples of ethylenediamine ethoxylated and/orpropoxylated, polyethyleneimine polymers that are suitable for use asthe polyamine polyether of the dewatering agent are sold by BASF inassociation with the names and trade designations Basorol® P DB-9390,Basorol® P DB-9392, Basorol® P DB-9360, and Basorol®P DB-9393. Anadditional example of an ethylenediamine ethoxylated and/orpropoxylated, polyethyleneimine polymer that is suitable for use as thepolyamine polyether of the dewatering agent is sold by Sasol inassociation with the name and trade designation Diammin™ EDA-72.

The resin alkoxylated oligomer of the dewatering agent may function,inter alia, as a demulsifier. In certain embodiments, the resinalkoxylated oligomer of the dewatering agent may be selected from thegroup of phenol formaldehyde ethoxylates, alkoxylated alkyl phenolformaldehyde resins, epoxy resin alkoxylates, poly diepoxideethoxylates, phenolic resins, methyloxirane polymers, phenolformaldehyde polymers with methyloxirane, phenol formaldehyde oxiranes,and any combination thereof. In certain embodiments, the resinalkoxylated oligomer of the demulsifying agent may be an ethoxylatedphenol formaldehyde resin or 4-nonylphenol formaldehyde withmethyloxirane and oxirane.

In certain embodiments, the treatment fluids of the present disclosuremay comprise proppant particulates. Examples of materials that may besuitable for use as proppant particulates in certain embodiments of thepresent disclosure include, but are not limited to, fly ash, silica,alumina, fumed carbon (e.g., pyrogenic carbon), carbon black, graphite,mica, titanium dioxide, metalsilicate, silicate, kaolin, talc, zirconia,boron, hollow microspheres (e.g., spherical shell-type materials havingan interior cavity), glass, sand, bauxite, sintered bauxite, ceramic,calcined clays (e.g., clays that have been heated to drive out volatilematerials), partially calcined clays (e.g., clays that have been heatedto partially drive out volatile materials), composite polymers (e.g.,thermoset nanocomposites), halloysite clay nanotubes, and anycombination thereof. The proppant particulates may be of any shape(regular or irregular) suitable or desired for a particular application.In some embodiments, the proppant particulates may be round or sphericalin shape, although they may also take on other shapes such as ovals,capsules, rods, toroids, cylinders, cubes, or variations thereof. Incertain embodiments, the proppant particulates of the present disclosuremay be relatively flexible or deformable, which may allow them to entercertain perforations, microfractures, or other spaces within asubterranean formation whereas solid particulates of a similar diameteror size may be unable to do so.

In certain embodiments, the treatment fluid may comprise the proppantparticulates in an amount from about 0.1 to about 10 pounds ofparticulates/gallon of treatment fluid (ppg). In other embodiments, thetreatment fluid may comprise the proppant particulates in an amount fromabout 0.1 ppg to about 5.0 ppg. In other embodiments, the treatmentfluid may comprise the proppant particulates in an amount from about 0.1ppg to about 0.5 ppg, in other embodiments, about 0.5 ppg to about 1.0ppg, in other embodiments, about 1.0 ppg to about 2.0 ppg, in otherembodiments, about 2.0 ppg 30 to about 3.0 ppg, in other embodiments,about 3.0 ppg to about 4.0 ppg, in other embodiments, about 4.0 ppg toabout 5.0 ppg, in other embodiments, about 5.0 ppg to about 6.0 ppg, inother embodiments, about 6.0 ppg to about 7.0 ppg, in other embodiments,about 7.0 ppg to about 8.0 ppg, in other embodiments, about 8.0 ppg toabout 9.0 ppg, and in other embodiments, about 9.0 ppg to about 10 ppg.

In certain embodiments, the treatment fluids of the present disclosurealso may comprise any number of additives. Examples of such additivesinclude, but are not limited to, salts, additional surfactants, acids,diverting agents, fluid loss control additives, gas, nitrogen, carbondioxide, surface modifying agents, tackifying agents, foamers, corrosioninhibitors, scale inhibitors, catalysts, clay stabilizers, shaleinhibitors, biocides, additional friction reducers, antifoam agents,bridging agents, flocculants, H₂S scavengers, CO₂ scavengers, oxygenscavengers, lubricants, hydrocarbons, viscosifying/gelling agents,breakers, weighting agents, relative permeability modifiers, resins,wetting agents, coating enhancement agents, filter cake removal agents,antifreeze agents (e.g., ethylene glycol), particulates, and the like. Aperson skilled in the art, with the benefit of this disclosure, willrecognize the types of additives that may be included in the treatmentfluids of the present disclosure for a particular application.

The treatment fluids of the present disclosure may be prepared using anysuitable method and/or equipment (e.g., blenders, mixers, stirrers,etc.) known in the art at any time prior to their use. The treatmentfluids may be prepared at least in part at a well site or at an offsitelocation. In certain embodiments, the water-soluble polymer, thedewatering agent, and/or other components of the treatment fluid may bemetered directly into a base fluid to form a treatment fluid. In certainembodiments, the base fluid may be mixed with the water-soluble polymer,the dewatering agent, and/or other components of the treatment fluid ata well site where the operation or treatment is conducted, either bybatch mixing or continuous (“on-the-fly”) mixing. The term “on-the-fly”is used herein to include methods of combining two or more componentswherein a flowing stream of one element is continuously introduced intoa flowing stream of another component so that the streams are combinedand mixed while continuing to flow as a single stream as part of theon-going treatment. Such mixing can also be described as “real-time”mixing. In other embodiments, the treatment fluids of the presentdisclosure may be prepared, either in whole or in part, at an offsitelocation and transported to the site where the treatment or operation isconducted.

The treatment fluids of the present disclosure may be introduced into aportion of a subterranean formation. The treatment fluid may be, forexample, a stimulation fluid, a hydraulic fracturing fluid, a drillingfluid, a spotting fluid, a clean-up fluid, a completion fluid, aremedial treatment fluid, a workover fluid, an abandonment fluid, apill, an acidizing fluid, a cementing fluid, a packer fluid, a loggingfluid, or a combination thereof. In introducing a treatment fluid of thepresent disclosure into a portion of a subterranean formation, thecomponents of the treatment fluid may be mixed together at the surface(or offsite prior to transport to the wellsite) and introduced into theformation together, or one or more components may be introduced into theformation at the surface separately from other components such that thecomponents mix or intermingle in a portion of the formation to form atreatment fluid. In either such case, the treatment fluid is deemed tobe introduced into at least a portion of the subterranean formation forpurposes of the present disclosure. In some embodiments, the variousother components of the water-soluble polymer, the dewatering agent,and/or other components of the treatment fluids of the presentdisclosure may be mixed into the treatment fluid during some stages butnot others. For example, the water-soluble polymer may be continuouslymixed into the treatment fluid, while the dewatering agent is only addedin selected stages, among other reasons, to enhance the viscosity and/orother properties of the fluid only during those stages.

The water-soluble polymer and the dewatering agent may be provided inany suitable fashion. In some embodiments, the water-soluble polymer andthe dewatering agent may be provided together (either by themselves orwith other optional components such as solvents and/or carrier fluids)and then mixed with the base fluid (and optionally other components)substantially simultaneously to form a treatment fluid of the presentdisclosure. In other embodiments, the water-soluble polymer and thedewatering agent may be mixed into the base fluid separately (eithersubstantially simultaneously or at different times). When addedseparately, the relative amounts and/or ratios of the water-solublepolymer and the dewatering agent added to the treatment fluid may bevaried throughout a particular operation. The water-soluble polymer andthe dewatering agent also may be mixed into the treatment fluid in anyorder and at any place in the mixing or fracturing equipment used in aparticular application of the present disclosure. For example, in someembodiments, the dewatering agent may be mixed into the fluid at thesame injection point as the water-soluble polymer (e.g., eye of thedischarge pump on a fracturing blender), or may be added to the fluidupstream or downstream of that injection point.

The present disclosure in some embodiments provides methods for usingthe treatment fluids to carry out hydraulic fracturing treatments(including fracture acidizing treatments). In certain embodiments, atreatment fluid may be introduced into a subterranean formation. In someembodiments, the treatment fluid may be introduced into a well bore thatpenetrates a subterranean formation. In some embodiments, the treatmentfluid may be introduced at a pressure sufficient to create or enhanceone or more fractures within the subterranean formation. In someembodiments, the treatment fluid may be introduced using one or morepumps. The treatment fluids used in these fracturing treatments mayinclude a number of different types of fluids, including but not limitedto pre-pad fluids, pad fluids, fracturing fluids, slickwater fluids,proppant-laden fluids, and the like.

FIG. 1 shows a well 100 during a fracturing operation in a portion of asubterranean formation of interest 102 surrounding a well bore 104. Thewell bore 104 extends from the surface 106, and the treatment fluid 108is applied to a portion of the subterranean formation 102 surroundingthe horizontal portion of the well bore. Although shown as verticaldeviating to horizontal, the well bore 104 may include horizontal,vertical, slant, curved, and other types of well bore geometries andorientations, and the fracturing treatment may be applied to asubterranean zone surrounding any portion of the well bore. The wellbore 104 can include a casing 110 that is cemented or otherwise securedto the well bore wall. The well bore 104 can be uncased or includeuncased sections. Perforations can be formed in the casing 110 to allowfracturing fluids and/or other materials to flow into the subterraneanformation 102. In cased wells, perforations can be formed using shapecharges, a perforating gun, hydro jetting and/or other tools.

The well is shown with a work string 112 depending from the surface 106into the well bore 104. A pump and blender system 120, which may includeblender 110, is coupled a work string 112 to pump the treatment fluid108 into the well bore 104. The working string 112 may include coiledtubing, jointed pipe, and/or other structures that allow fluid to flowinto the well bore 104. The working string 112 can include flow controldevices 122 (e.g., bypass valves, ports, and or other tools or welldevices) that control a flow of fluid from the interior of the workingstring 112 into the subterranean zone 102. For example, the workingstring 112 may include ports adjacent the well bore wall to communicatea treatment fluid 108 (e.g., fracturing fluid, pad fluids, pre-padfluids, spacer fluids, as well as other fluids) directly into thesubterranean formation 102, and/or the working string 112 may includeports that are spaced apart from the well bore wall to communicatetreatment fluid 108 and/or other fluids into an annulus in the well borebetween the working string 112 and the well bore wall. The workingstring 112 and/or the well bore 104 may include one or more sets ofpackers 114 that seal the annulus between the working string 112 andwell bore 104 to define an interval of the well bore 104 into which atreatment fluid 108 or other fluids will be pumped. FIG. 1 shows twopackers 114, one defining an uphole boundary of the interval and onedefining the downhole end of the interval.

In certain embodiments, the treatment fluid 108 may be introduced intothe well bore 104 at or above at or above a certain hydraulic pressure.In such embodiments, when the treatment fluid 108 (e.g., a fracturingfluid) is pumped into the desired interval of the well bore 104 at orabove a certain hydraulic pressure, the rock of the subterranean zone102 “fractures,” in that one or more fractures or cracks are created inthe zone or one or more existing fractures or cracks in the zone 102 areenlarged or enhanced. In the embodiments shown, the rock matrix of thesubterranean zone 102 is of a type that, when fractured, produces both aprimary fracture 116 in the near field and secondary fractures 118(e.g., induced, dendritic fractures or microfractures) in the far field.The secondary fractures 118 have propagated from or near the ends andedges of the primary fracture 116. In certain instances, thesubterranean zone 102 is a low permeability zone having a permeabilityof 1 mD or less. For example, the subterranean zone 102 can include ashale, tight gas, clay, and/or coal bed formation. In certain instances,the rock matrix of the subterranean zone 102 may include cleating ornatural fractures (i.e., those that existed prior to, and were notcaused by, a fracture treatment). The natural fractures tend to rungenerally in a direction that is parallel to the primary fracture 116.The secondary fractures 118 run in many directions including directionsnon-parallel and, in certain instances, perpendicular to the directionof the primary fracture 116. As a result, the secondary fracture 118 cancross, and thereby link, the natural fractures to the primary fracture116. In certain embodiments, the proppant particulates in the treatmentfluid 108 may enter and/or be deposited within one or more of theprimary fracture 116 and/or the secondary fractures 108.

To facilitate a better understanding of the present disclosure, thefollowing examples of certain aspects of certain embodiments are given.The following examples are not the only examples that could be givenaccording to the present disclosure and are not intended to limit thescope of the disclosure or claims.

EXAMPLES Example 1

As shown in Table 1 below, six fluid samples were prepared, eachcomprising 250 mL of Houston tap water and 0.4 wt. % of a latex-basedwater-soluble polymer (i.e., friction reducer) of the present disclosureby volume of the sample. Sample 1 contained only these components.Sample 2 further contained 0.1 wt. % of a dewatering agent of thepresent disclosure by volume of the sample. The dewatering agentcomprised a solvent comprising dimethyl 2-methylglutarate (a brancheddibasic ester), a co-solvent comprising isopropanol, an ethoxylatedalcohol comprising a C₁₂-C₁₄ ethoxylated alcohol (7EO), a resinalkoxylated oligomer comprising phenol formaldehyde with methyloxiraneand oxirane, and a polyamine polyether comprising an alkoxylatedpolyamine. Samples 3-6 each further contained 0.02 wt. % of onecomponent of the dewatering agent used in Sample 2 by volume of thesample—the solvent, the ethoxylated alcohol, the resin alkoxylatedoligomer, and the polyamine polyether, respectively.

TABLE 1 Component Sample (% weight by volume of sample) 1 2 3 4 5 6Houston Tap Water 250 mL 250 mL 250 mL 250 mL 250 mL 250 mL FrictionReducer 0.4% 0.4% 0.4%  0.4%  0.4%  0.4%  Solvent — 0.02% 0.02% — — —Co-Solvent — 0.02% — — — — Ethoxylated Alcohol — 0.02% — 0.02% — — ResinAlkoxylated Oligomer — 0.02% — — 0.02% — Polyamine Polyether — 0.02% — —0.02%

Each sample was blended, and the friction reducer in each sample wasallowed to hydrate for 4 minutes and 10 seconds at room temperature. Theviscosity of each samples was then measured at the following 40 s⁻¹, 170s⁻¹, and 511 s⁻¹ shear rates using an Anton Paar Model 501 rheometerequipped with double gap and cone-plate measuring arrangements. Theresults are shown in FIG. 2. As shown in FIG. 2, the inclusion of adewatering agent with a friction reducer according to certainembodiments of the present disclosure resulted in a synergisticimprovement of the viscosity of the fluid samples (Sample 2) as comparedto the inclusion of the friction reducer alone (Sample 1), particularlyat a low shear rate (40 s⁻¹). As also shown in FIG. 2, the component ofthe dewatering agent that appears to be most responsible for thissynergistic effect is the solvent comprising a branched dibasic ester asSample 3 yielded higher viscosities than Sample 4-6.

Example 2

As shown in Table 2 below, six fluid samples were prepared, eachcomprising 250 mL of deionized water and 0.4 wt. % of a latex-basedwater-soluble polymer (i.e., friction reducer) of the present disclosureby volume of the sample. Samples 1, 3, and 5 contained only thesecomponents. Samples 2, 4, and 6 further comprised 0.1 wt. % of adewatering agent of the present disclosure by volume of the sample. Thedewatering agent comprised a solvent comprising dimethyl2-methylglutarate, a co-solvent comprising isopropanol, an ethoxylatedalcohol comprising a C₁₂-C₁₄ ethoxylated alcohol (7EO), a resinalkoxylated oligomer comprising phenol formaldehyde with methyloxiraneand oxirane, and a polyamine polyether comprising an alkoxylatedpolyamine.

Each sample was blended, and the friction reducer in each sample wasallowed to hydrate for 4 minutes and 10 seconds at the temperaturesindicated in Table 2 below. The viscosity of each samples was thenmeasured at the following 40 s⁻¹, 170 s⁻¹, and 511 s⁻¹ shear rates usingan Anton Paar Model 501 rheometer equipped with double gap andcone-plate measuring arrangements. The results are shown in Table 2.

TABLE 2 40 170 511 Temp. Sample Composition s⁻¹ s⁻¹ s⁻¹  75° F 1 Water +Friction Reducer 56.02 24.76 14.55 2 Water + Friction Reducer + 125.4247.11 25.05 Dewatering Agent 150° F 3 Water + Friction Reducer 41.3817.69 10.12 4 Water + Friction Reducer + 79.11 32.07 16.86 DewateringAgent 180° F 5 Water + Friction Reducer 34.52 15.07 8.17 6 Water +Friction Reducer + 67.65 26.22 13.28 Dewatering Agent

As shown in Table 2, the inclusion of a dewatering agent with a frictionreducer according to certain embodiments of the present disclosureresulted in a synergistic improvement of the viscosity of the fluidsamples (Samples 2, 4, 6) as compared to the inclusion of the frictionreducer alone (Samples 1, 3, 5, respectively), particularly at a lowshear rate (40 s⁻¹). As also shown in Table 2, this synergisticimprovement occurred over a range of temperatures from 75° F. to 180° F.

Example 3

As shown in Table 3 below, ten fluid samples were prepared, eachcomprising 250 mL of Houston tap water and 0.4 wt. % of a latex-basedwater-soluble polymer (i.e., friction reducer) of the present disclosureby volume of the sample. Friction reducer A in Samples 1-5 comprised afirst anionic polyacrylamide polyacrylate copolymer. Friction reducer Bin Samples 6-10 comprised a second anionic polyacrylamide polyacrylatecopolymer. As also shown in Table 3 below, Samples 2 and 7 furthercomprised 0.1 wt. % of a dewatering agent of the present disclosure byvolume of the sample. The dewatering agent comprised a solventcomprising dimethyl 2-methylglutarate, a co-solvent comprisingisopropanol, an ethoxylated alcohol comprising a C₁₂-C₁₄ ethoxylatedalcohol (7EO), a resin alkoxylated oligomer comprising phenolformaldehyde with methyloxirane and oxirane, and a polyamine polyethercomprising an alkoxylated polyamine. As further shown in Table 3 below,Samples 3-5 and 8-10 further comprised 0.1 wt. % of another surfactantformulations known in the art: non-ionic flowback aid (SurfactantFormulation 1), a non-ionic microemulsion demulsifier formulation(Surfactant Formulation 2), and a non-ionic microemulsion flowbackenhancer (Surfactant Formulation 3).

Each sample was blended, and the friction reducer in each sample wasallowed to hydrate for 4 minutes and 10 seconds at 75° F. The viscosityof each samples was then measured at the following 40 s⁻¹, 170 s⁻¹, and511 s⁻¹ shear rates using an Anton Paar Model 501 rheometer equippedwith double gap and cone-plate measuring arrangements. The results areshown in Table 3.

TABLE 3 Sample 40 s⁻¹ 170 s⁻¹ 511 s⁻¹ 1 Water + Friction Reducer A 49.924 13.75 2 Water + Friction Reducer A + 76.19 34.28 18.67 DewateringAgent 3 Water + Friction Reducer A + 53.51 25.35 14.34 SurfactantFormulation 1 4 Water + Friction Reducer A + 50.31 24.02 13.69Surfactant Formulation 2 5 Water + Friction Reducer A + 52.1 24.66 13.96Surfactant Formulation 3 6 Water + Friction Reducer B 49.52 23.88 13.717 Water + Friction Reducer B + 57.21 28.44 16.71 Dewatering Agent 8Water + Friction Reducer B + 44.32 21.81 12.72 Surfactant Formulation 19 Water + Friction Reducer B + 36.59 20.9 13.65 Surfactant Formulation 210 Water + Friction Reducer B + 41.3 22.82 14.53 Surfactant Formulation3

As shown in Table 3, the inclusion of a dewatering agent with a frictionreducer according to certain embodiments of the present disclosureresulted in a synergistic improvement of the viscosity of the fluidsamples (Samples 2 and 7) as compared to the inclusion of the frictionreducer alone (Samples 1 and 6, respectively), particularly at a lowshear rate (40 s⁻¹). As also shown in Table 3, the dewatering agent ofthe present disclosure has a more significant synergistic improvement ofthe viscosity of the fluid samples (Samples 2 and 7) than the othersurfactant formulations known in the art (Samples 3-5 and 8-10,respectively).

Example 4

Two fluid samples were prepared, each comprising 250 mL of HoustonMunicipal tap water and 1.0 wt. % of a latex-based water-soluble polymer(i.e., friction reducer) of the present disclosure by volume of thesample. The first fluid contained only these components. The secondfluid further included 1.0 wt. % of a dewatering agent of the presentdisclosure by volume of the sample. The dewatering agent comprised asolvent comprising dimethyl 2-methylglutarate, a co-solvent comprisingisopropanol, an ethoxylated alcohol comprising a C₁₂-C₁₄ ethoxylatedalcohol (7EO), a resin alkoxylated oligomer comprising phenolformaldehyde with methyloxirane and oxirane, and a polyamine polyethercomprising an alkoxylated polyamine. As shown in FIG. 3, the percentageof friction reduction achieved by each fluid sample was measured by pipeflow loop for about 26 minutes. As shown in FIG. 3, both fluid samplesachieved over 60% friction reduction for over 20 minutes. Thus, Example4 demonstrates that the compositions of the present disclosure mayincrease the viscosity of treatment fluids while maintaining frictionreduction abilities.

An embodiment of the present disclosure is a method that includes:adding an anionic or amphoteric water-soluble polymer to a treatmentfluid comprising an aqueous base fluid; adding a dewatering agent to thetreatment fluid, wherein the dewatering agent comprises an aqueousphase, a solvent, a co-solvent, and one or more surfactants selectedfrom the group consisting of: ethoxylated alcohol, a polyaminepolyether, a resin alkoxylated oligomer, and any combination thereof;and introducing the treatment fluid into a well bore penetrating atleast a portion of the subterranean formation.

Another embodiment of the present disclosure is a method that includes:introducing a treatment fluid comprising an aqueous base fluid, ananionic or amphoteric water-soluble polymer, and a dewatering agent intoa well bore penetrating at least a portion of the subterraneanformation, wherein the dewatering agent comprises one or moresurfactants and a solvent that is selected from the group consisting of:methyl 9-decenoate, methyl 9-dodecenoate, N,N-dimethyl 9-decenamide,diethyl carbonate, triethyl citrate, dimethyl 2-methylglutarate, dodecylacetate, 1-dodecyl-2-pyrrolidinone, 2-dodecyl-pyrrolidinone,N—(C₂H₄)_(n)CH₃-pyrrolidinone, wherein n is from about 1 to about 22,n-octyl-pyrrolidinone, dibutyl ether, isoamyl ether, di-n-amyl ether,dihexyl ether, heptyl ether, dioctyl ether, dodecyl ether, benzyl hexylether, a di-n-alkyl-ether having the formula O[(CH₂)_(x)CH₃]₂, wherein xis from about 3 to about 35, a dibasic ester having the formulaCH₃OC(O)(CH₂)_(m)C(O)OCH₃, wherein m is from about 2 to about 4, and anycombination thereof.

Another embodiment of the present disclosure is a composition thatincludes: an anionic or amphoteric water-soluble polymer; and adewatering agent that comprises: an aqueous phase, a solvent, aco-solvent, and one or more surfactants selected from the groupconsisting of: ethoxylated alcohol, a polyamine polyether, a resinalkoxylated oligomer, and any combination thereof.

Therefore, the present disclosure is well adapted to attain the ends andadvantages mentioned as well as those that are inherent therein. Theparticular embodiments disclosed above are illustrative only, as thepresent disclosure may be modified and practiced in different butequivalent manners apparent to those skilled in the art having thebenefit of the teachings herein. While numerous changes may be made bythose skilled in the art, such changes are encompassed within the spiritof the subject matter defined by the appended claims. Furthermore, nolimitations are intended to the details of construction or design hereinshown, other than as described in the claims below. It is thereforeevident that the particular illustrative embodiments disclosed above maybe altered or modified and all such variations are considered within thescope and spirit of the present disclosure. In particular, every rangeof values (e.g., “from about a to about b,” or, equivalently, “fromapproximately a to b,” or, equivalently, “from approximately a-b”)disclosed herein is to be understood as referring to the power set (theset of all subsets) of the respective range of values. The terms in theclaims have their plain, ordinary meaning unless otherwise explicitlyand clearly defined by the patentee.

What is claimed is:
 1. A method comprising: adding an anionic oramphoteric water-soluble polymer to a treatment fluid comprising anaqueous base fluid; adding a dewatering agent to the treatment fluid,wherein the dewatering agent comprises an aqueous phase, a solvent, aco-solvent, and one or more surfactants selected from the groupconsisting of: ethoxylated alcohol, a polyamine polyether, a resinalkoxylated oligomer, and any combination thereof; and introducing thetreatment fluid into a well bore penetrating at least a portion of thesubterranean formation.
 2. The method of claim 1, wherein the solvent isselected from the group consisting of: methyl 9-decenoate, methyl9-dodecenoate, N,N-dimethyl 9-decenamide, diethyl carbonate, triethylcitrate, dimethyl 2-methylglutarate, dodecyl acetate,1-dodecyl-2-pyrrolidinone, 2-dodecyl-pyrrolidinone,N—(C₂H₄)_(n)CH3-pyrrolidinone, wherein n is from about 1 to about 22,n-octyl-pyrrolidinone, dibutyl ether, isoamyl ether, di-n-amyl ether,dihexyl ether, heptyl ether, dioctyl ether, dodecyl ether, benzyl hexylether, a di-n-alkyl-ether having the formula O[(CH₂)_(x)CH₃]₂, wherein xis from about 3 to about 35, a dibasic ester having the formulaCH₃OC(O)(CH₂)_(m)C(O)OCH₃, wherein m is from about 2 to about 4, and anycombination thereof.
 3. The method of claim 1, wherein the water-solublepolymer and the dewatering agent are combined before being added to thetreatment fluid.
 4. The method of claim 1, wherein the treatment fluidhas a higher viscosity than a treatment fluid comprising thewater-soluble polymer without the dewatering agent.
 5. The method ofclaim 1, wherein the treatment fluid further comprises a plurality ofproppant particulates, and wherein the method further comprisesdepositing at least a portion of the proppant particulates in one ormore fractures within the subterranean formation.
 6. The method of claim1, wherein the water-soluble polymer is a latex-based component.
 7. Themethod of claim 1, wherein the water-soluble polymer is present in thetreatment fluid in an amount from about 0.05 wt. % to about 1.5 wt. % byvolume of the treatment fluid
 8. The composition of claim 1, wherein thetreatment fluid is present in the treatment fluid in an amount fromabout 0.001 wt. % to about 4 wt. % by volume of the treatment fluid. 9.A method comprising: introducing a treatment fluid comprising an aqueousbase fluid, an anionic or amphoteric water-soluble polymer, and adewatering agent into a well bore penetrating at least a portion of thesubterranean formation, wherein the dewatering agent comprises one ormore surfactants and a solvent that is selected from the groupconsisting of: methyl 9-decenoate, methyl 9-dodecenoate, N,N-dimethyl9-decenamide, diethyl carbonate, triethyl citrate, dimethyl2-methylglutarate, dodecyl acetate, 1-dodecyl-2-pyrrolidinone,2-dodecyl-pyrrolidinone, N—(C₂H₄)_(n)CH3-pyrrolidinone, wherein n isfrom about 1 to about 22, n-octyl-pyrrolidinone, dibutyl ether, isoamylether, di-n-amyl ether, dihexyl ether, heptyl ether, dioctyl ether,dodecyl ether, benzyl hexyl ether, a di-n-alkyl-ether having the formulaO[(CH₂)_(x)CH₃]₂, wherein x is from about 3 to about 35, a dibasic esterhaving the formula CH₃OC(O)(CH₂)_(m)C(O)OCH₃, wherein m is from about 2to about 4, and any combination thereof.
 10. The method of claim 9,wherein the dewatering agent further comprises an aqueous phase and aco-solvent.
 11. The method of claim 9, wherein the one or moresurfactants are selected from the group consisting of: ethoxylatedalcohol, a polyamine polyether, a resin alkoxylated oligomer, and anycombination thereof.
 12. The method of claim 9, wherein the solvent is alinear dibasic ester, a branched dibasic ester, or any combinationthereof.
 13. The method of claim 9, wherein the treatment fluid isintroduced into the subterranean formation at or above a pressuresufficient to create or enhance at least one fracture in thesubterranean formation.
 14. The method of claim 9, wherein the treatmentfluid further comprises a plurality of proppant particulates, andwherein at least a portion of the proppant particulates are deposited inone or more fractures within the subterranean formation.
 15. Acomposition comprising: an anionic or amphoteric water-soluble polymer;and a dewatering agent that comprises: an aqueous phase, a solvent, aco-solvent, and one or more surfactants selected from the groupconsisting of: ethoxylated alcohol, a polyamine polyether, a resinalkoxylated oligomer, and any combination thereof.
 16. The compositionof claim 15 further comprising an aqueous base fluid, wherein theaqueous base fluid contains the water-soluble polymer and the dewateringagent.
 17. The composition of claim 16, wherein the water-solublepolymer is present in the composition in an amount from about 0.05 wt. %to about 1.5 wt. % by volume of the composition.
 18. The composition ofclaim 16, wherein the dewatering agent is present in the composition inan amount from about 0.001 wt. % to about 4 wt. % by volume of thecomposition.
 19. The composition of claim 15, wherein the solvent isselected from the group consisting of: methyl 9-decenoate, methyl9-dodecenoate, N,N-dimethyl 9-decenamide, diethyl carbonate, triethylcitrate, dimethyl 2-methylglutarate, dodecyl acetate,1-dodecyl-2-pyrrolidinone, 2-dodecyl-pyrrolidinone,N—(C₂H₄)_(n)CH₃-pyrrolidinone, wherein n is from about 1 to about 22,n-octyl-pyrrolidinone, dibutyl ether, isoamyl ether, di-n-amyl ether,dihexyl ether, heptyl ether, dioctyl ether, dodecyl ether, benzyl hexylether, a di-n-alkyl-ether having the formula O[(CH₂)_(x)CH₃]₂, wherein xis from about 3 to about 35, a dibasic ester having the formulaCH₃OC(O)(CH₂)_(m)C(O)OCH₃, wherein m is from about 2 to about 4, and anycombination thereof.
 20. The composition of claim 15, wherein thewater-soluble polymer is a latex-based component.